Calcium bromide in drilling and completion fluids

Weight that holds the well

A fluid column controls a well through hydrostatic pressure. In field units, pressure in psi equals 0.052 × fluid density (lb/gal) × true vertical depth (ft). Raising density raises the pressure the fluid exerts at depth.

Drilling muds get their weight from suspended solids such as barite. A completion brine gets it from dissolved salt, so there is nothing to settle out or to plug perforations and pay-zone pores.

Where calcium bromide fits

Typical density ranges

Calcium chloride (CaCl₂)

up to ≈ 11.6 ppg

Calcium bromide (CaBr₂)

up to ≈ 15.3 ppg

CaCl₂ / CaBr₂ blends

≈ 11.7–15.1 ppg

CaBr₂ / ZnBr₂ blends

up to ≈ 19.2 ppg

Ranges are typical industry figures. Actual density depends on temperature, salt ratio and water content.

Typical uses

• Completion fluids placed across the pay zone.
• Workover and kill fluids that control the well during intervention.
• Packer fluids left in the annulus above the packer.
• Perforating and drill-in fluids where formation damage must be minimal.
• HPHT wells where high density and thermal stability are needed.

Brines can be corrosive to some metals and elastomers. Corrosion inhibitors, material selection and filtration belong in every brine programme.

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